Búsqueda Imágenes Maps Play YouTube Noticias Gmail Drive Más »
Iniciar sesión
Usuarios de lectores de pantalla: deben hacer clic en este enlace para utilizar el modo de accesibilidad. Este modo tiene las mismas funciones esenciales pero funciona mejor con el lector.

Patentes

  1. Búsqueda avanzada de patentes
Número de publicaciónUS4829100 A
Tipo de publicaciónConcesión
Número de solicitudUS 07/112,782
Fecha de publicación9 May 1989
Fecha de presentación23 Oct 1987
Fecha de prioridad23 Oct 1987
TarifaPagadas
También publicado comoCA1334692C, DE3850841D1, DE3850841T2, EP0313243A2, EP0313243A3, EP0313243B1
Número de publicación07112782, 112782, US 4829100 A, US 4829100A, US-A-4829100, US4829100 A, US4829100A
InventoresJoseph R. Murphey, Kenneth D. Totty
Cesionario originalHalliburton Company
Exportar citaBiBTeX, EndNote, RefMan
Enlaces externos: USPTO, Cesión de USPTO, Espacenet
Continuously forming and transporting consolidatable resin coated particulate materials in aqueous gels
US 4829100 A
Resumen
Methods of continuously forming and suspending consolidatable resin composition coated particulate material in a gelled aqueous carrier liquid and transporting the coated particulate material by way of the gelled aqueous carrier liquid to a zone in which the sand is consolidated. In accordance with the methods, substantially continuous streams of a gelled aqueous carrier liquid, uncoated particulate material, a resin composition which will subsequently harden and a surface active agent are admixed whereby the particulate material is continuously coated with the resin composition and suspended in the gelled aqueous carrier liquid.
Imágenes(2)
Previous page
Next page
Reclamaciones(17)
What is claimed is:
1. A method of continuously forming and suspending consolidatable resin composition coated particulate material in a gelled aqueous carrier liquid comprising intermixing substantially continuous streams of said gelled aqueous carrier liquid, prepared by admixing from about 20 to 120 pounds of a hydratable polysaccharide having a molecular weight of from about 100,000 to about 4,000,000 with an aqueous carrier liquid per 1000 gallons of said carrier liquid, a particulate material, a resin composition which will subsequently harden and a surface active agent whereby said particulate material is substantially continuously coated with said resin composition and suspended in said gelled aqueous carrier liquid, said resin composition comprising a hardenable polyepoxide resin, a hardening agent for said resin, a substantially water immiscible reactive diluent and substantially water immiscible non-reactive diluent for said resin, said reactive and non-reactive diluents being present in said resin composition in amouns sufficient to lower the viscosity of the resin composition to a level in the range of from about 100 to about 800 centipoises at ambient temperature.
2. A method of claim 1 wherein said reactive diluent is present in an amount of from about 2 to about 35 parts per 100 parts by weight of said polyepoxide resin and said non-reactive diluent is present in an amount of from about 4 to about 20 parts per 100 parts by weight of said polyepoxide resin.
3. The method of claim 1 wherein said non-reactive diluent is selected from the group consisting of compounds having the structural formula: ##STR3## wherein R is (Cn H2n+1) wherein n is an integer in the range of from about 1 to about 5;
R1 is (Cm H2m+1) wherein m is O or an integer in the range of from 1 to about 4, or ##STR4## wherein y is an integer in the range of from 1 to about 4, and X is H or OH; and
R2 is Ca H2a wherein a is an integer in the range of from 2 to about 5.
4. The method of claim 1 wherein said reactive diluent comprises at least one member selected from the group of butyl glycidyl ether, cresol glycidyl ether, alkyl glycidyl ether and phenyl glycidyl ether.
5. The method of claim 1 wherein said gelled aqueous carrier liquid comprises an aqueous fluid gelled with a polysaccharide comprising at least one member selected from the group of galactomannon gum and derivatives thereof.
6. The method of claim 1 defined further to include admixing a crosslinking agent for said polysaccharide comprising at least one member from the group consisting of titanium, aluminum and zirconium chelates or salts and borate salts with said gelled aqueous carrier liquid.
7. The method of claim 1 wherein said polyepoxide resin is comprised of the condensation product of epichlorohydrin and bisphenol A.
8. The method of claim 1 wherein said hardening agent is a liquid eutectic mixture of methylene dianiline and metaphenylene diamine diluted with a water soluble solvent.
9. The method of claim 1 wherein said surface active agent includes a non-cationic surfactant comprising at least one member selected from the group consisting of ethoxylated fatty acids produced by reacting fatty acids containing from about 12 to about 22 carbon atoms with from about 5 to about 20 moles of ethylene oxide per mole of fatty acid and mixtures of said ethoxylated fatty acids with unreacted fatty acids.
10. A method of continuously forming and suspending consolidatable resin composition coated particulate material in a gelled aqueous carrier liquid comprising intermixing substantially continuous streams of an aqueous carrier liquid gelled by the addition of a polysaccharide polymer thereto, a particulate material, a surface active agent including a noncationic surfactant and a resin composition which will subsequently harden whereby said particulate material is substantially continuously coated with said resin composition and suspended in said gelled aqueous carrier liquid, said resin composition comprising a hardenable polyepoxide resin, at least one substantially water immiscible first diluent for said resin, a second diluent which is non-reactive with said resin and a hardening agent for said resin, said diluents being present in said resin composition in an amount sufficient to lower the viscosity of the resin composition to a level in the range of from about 100 to about 800 centipoises at ambient temperature and said polysaccharide is present in said aqueous carrier liquid in an amount of from about 20 to about 120 pounds per 1000 gallons of said carrier liquid.
11. The method of claim 10 wherein said non-cationic surfactant comprises at least one member selected from the group consisting of ethoxylated fatty acids produced by reacting fatty acids containing from about 12 to about 22 carbon atoms with from about 5 to about 20 moles of ethylene oxide per mole of fatty acid and mixtures of said ethoxylated fatty acids with unreacted fatty acids.
12. The method of claim 10 wherein said second diluent includes at least one member selected from the group consisting of compounds having the structural formula: ##STR5## wherein R is (Cn H2n+1) wherein n is an integer in the range of from about 1 to about 5;
R1 is (Cm H2m+1) wherein m is O or an integer in the range of from 1 to about 4 or ##STR6## the range of from about 1 to about 4 and X is H or OH; and R2 is Ca H2a wherein a is an integer in the range of from about 2 to about 5.
13. The method of claim 12 wherein said substantially water immiscible diluent includes at least one member selected from the group of butyl glycidyl ether, cresol glycidyl ether, allyl glycidyl ether and phenyl glycidyl ether.
14. The method of claim 10 wherein said polyepoxide resin is comprised of the condensation product of epichlorohydrin and bisphenol A and said hardening agent is a liquid eutectic mixture of methylene dianiline and metaphenylene diamine diluted with a water soluble solvent.
15. The method of claim 10 defined further to include the steps of introducing the resulting substantially continuous stream of gelled aqueous carrier liquid having resin composition coated particulate material suspended therein into a zone in a subterranean formation; and allowing said resin composition to harden whereby said particulate material is caused to form a hard permeable mass in said zone.
16. The method of claim 15 wherein said zone comprises at least one member selected from the group of a wellbore penetrating said subterranean formation and a fracture created or present in said subterranean formation.
17. The method of claim 10 wherein said second diluent comprises at least one member selected from the group consisting of compounds having the structural formula: ##STR7## wherein R is (Cn H2n+1) wherein n is an integer in the range of from about 1 to about 5;
R1 is Cm H2m+1) wherein m is O or an integer in the range of from about 1 to about 4 or ##STR8## wherein y is an integer in the range of from about 1 to about 4 and X is H or OH; and
R2 is Ca H2a wherein a is an integer in the range of from about 2 to about 5, said member being present in an amount of from about 4 to about 20 parts per 100 parts by weight of said polyepoxide resin and said first diluent comprises at least one member selected from the group consisting of butyl glycidyl ether, cresol glycidyl ether, allyl glycidyl ether and phenyl glycidyl ether , present in an amount of from about 2 to about 35 parts per 100 parts by weight of said polyepoxide resin.
Descripción
BACKGROUND OF THE INVENTION

1. Field of the Invention

This invention provides a method of continuously coating a particulate material with a resin in the presence of an aqueous gel. The product of the method, a resin-coated particulate material, is especially useful in the treatment of subterranean oil and gas producing formations for the purpose of forming consolidations of the particulate material therein. The consolidations function to help control loose formation sand and to help retain loose proppants placed in fractures formed therein.

2. Description of the Prior Art

Processes and techniques have been developed for consolidating particulate material, e.g., sand, into a hard permeable mass in a subterranean zone.

These processes are useful in treating a subterranean formation containing loose or incompetent sands which migrate with hydrocarbons produced therefrom. The consolidated particulate material reduces or prevents such migration when it is placed between the producing formation and the well bore penetrating the formation. The formation of the consolidated, permeable, particulate mass has been accomplished by coating formation sand adjacent the well bore with a hardenable resin, and then causing the resin to harden. An alternate technique has been to coat sand with a resin on the surface, to suspend the coated sand in a carrier liquid and then to pump the suspension by way of the well bore into the formation containing loose or incompetent sands to deposit the coated sand therein. The resin on the deposited sand is then caused or permitted to harden whereby a consolidated, hard permeable mass is formed between the well bore and the loose or incompetent sands in the formation.

The previously developed methods have been used successfully in applications featuring resin coating of particulate material by batch mixing of component streams, but these methods have not been desirable in applications which require the rapid coating of particulate material suspended in continuous streams of a carrier liquid. For example, it is often necessary that resin-coated particulate material be continuously carried into a subterranean formation by a gelled aqueous carrier liquid for a relatively long period of time in order to deposit the resin-coated material and hold it in place against the face of the formation or to deposit the material in fractures formed in the formation. In such applications, if the flow rate of the carrier liquid is reduced or interrupted, the resin coated particulate material carried in the liquid can be deposited in undesired locations such as in surface equipment or in the well bore instead of in formation fractures or other specific desired locations.

The batch mixing methods for producing continuous streams of gelled aqueous carrier liquids containing resin coated particulate materials are time-consuming and expensive and are attended by risks of flow rate interruption or reduction. For example, U.S. Pat. No. 4,074,760 describes a method of forming a consolidated particulate mass in a subterranean formation wherein sand, coated with a resin, is suspended in a gelled aqueous carrier liquid. The carrier liquid is introduced into a subterranean zone whereby the resin coated sand is deposited and subsequently consolidated therein. The preparation of the suspension of carrier liquid and coated sand involves the batch mixing of components, i.e., the gelled aqueous carrier liquid containing sand is prepared separately from the resin followed by the batch mixing of the two for the period of time required to coat the sand with the resin.

U.S. Pat. No. 4,199,484 discloses a method of preparing a suspension of a particulate material coated with an epoxy resin in a gelled aqueous carrier liquid wherein the coating of the sand is carried out in the gelled aqueous carrier liquid. According to this method, the gelled carrier liquid, sand and other components are first combined followed by the addition of the epoxy resin with mixing whereby the epoxy resin coats the sand. The batch mixing of the components requires a period of time, e.g., at least about 15 minutes to several hours to obtain satisfactory coating of the particulate material before the slurry may be introduced into a placement zone. These prior art methods for forming suspensions of gelled aqueous carrier liquid and resin coated particulate material are not carried out on a substantially instantaneous and continuous basis.

SUMMARY OF THE INVENTION

By the present invention, a method of rapidly and continuously forming a consolidatable, resin-coated, particulate material in the presence of an aqueous gelled carrier liquid is provided to produce a gelled carrier liquid containing the coated particulate material suspended therein; the suspension can be continuously introduced into a subterranean zone over an extended period of time.

The method is comprised of substantially continuously admixing streams of gelled aqueous carrier liquid, particulate material, a resin composition and a surface active agent. The particulate material is substantially continuously coated with the resin and suspended in the gelled aqueous carrier liquid.

A substantially continuous stream of the gelled aqueous carrier liquid having the coated particulate material suspended therein can be introduced into a subterranean formation over the period of time necessary to deposit therein the quantity of coated particulate material required to form the desired hard permeable mass. The resin on the coated particulate material is then allowed to harden whereby the deposit is consolidated into a hard permeable mass in the formation.

The method of the present invention and the various chemical components useful therein are described in detail in the Description of Preferred Embodiments which follows.

BRIEF DESCRIPTION OF THE DRAWING

FIG. 1 is a schematic illustration of one system of apparatus for performing the methods of the present invention.

FIG. 2 is a schematic illustration of laboratory apparatus used for simulating the performance of the methods the invention in the field.

DESCRIPTION OF PREFERRED EMBODIMENTS

In accordance with the methods of the present invention, a substantially continuous stream of particulate material, e.g., sand, is substantially instantaneously coated with a continuous stream of resin which will subsequently harden; the coated particulate material is simultaneously suspended in a gelled aqueous carrier liquid. The resin has a sufficiently long curing or working time to enable continuous deposition of the suspension of gelled aqueous carrier liquid and coated particulate material in a desired location of a subterranean zone. Subsequent hardening of the resin in the zone produces the desired hard permeable mass of consolidated particulate material.

The gelled aqueous carrier liquids utilized in this invention are formed by hydrating polysaccharide polymer gelling agents in fresh water, brine or seawater. The polysaccharide polymer gelling agents useful have molecular weights in the range of from about 100,000 to 4,000,000, preferably from about 600,000 to about 2,400,000, and are preferably cellulose or guar derivatives. The polymers include substituents such as hydroxy ethyl to give the necessary water hydration and gel characteristics to produce a clear aqueous gel having a viscosity of at least about 30 centipoises (reading on Fann V.G. meter at 300 rpm). Preferred polymers include substituted carboxy and hydroxy alkyl cellulose, such as hydroxyethylcellulose and carboxymethylhydroxyethylcellulose, and substituted hydroxy alkyl guar, such as hydroxypropylguar. Most preferably, the gelling agent is hydroxypropylguar or carboxymethylhydroxypropyl guar having a molecular weight in the range of from about 100,000 to about 4,000,000, and having a propylene oxide substitution (M.S.) of about 0.1 to about 0.7 moles propylene oxide per mole of mannose and galactose in the guar.

The gelled aqueous carrier liquid is preferably prepared by combining the polysaccharide polymer utilized with the aqueous liquid used in an amount in the range of from about 20 to about 120 pounds of polymer per 1,000 gallons of water, brine or seawater to form a gelled aqueous liquid having a viscosity in the range of from about 10 centipoises aqueous carrier liquid includes from about 30 to about 80 pounds of gelling agent per 1000 gallons of water, brine or seawater, and has a viscosity of from about 15 to about 100 centipoises.

The gelled aqueous carrier liquid preferably contains a gel breaker which serves to reduce the viscosity of the gel at a time substantially coincident with the completion of the placement of the coated particulate material at the desired location in a subterranean formation. That is, the gel breaker causes the gelled carrier liquid to revert to a low viscosity liquid which readily separates from the deposited particulate material and leaks-off into permeable strata surrounding the deposit location.

As mentioned above, breaking the gelled carrier liquid allows it to separate from the particulate material and enter or filter into permeable strata adjacent the deposit location. While a variety of gel breakers which are well known in the prior art can be utilized, an enzyme-type breaker such as cellulase for a substituted cellulose gelling agent and a hemi-cellulase for a substituted galactomannan gelling agent are preferred.

As is well known in the art, relatively small quantities of the enzyme breaker used are generally required, but as is well known in the art, the particular quantity depends upon the pH, temperature, and specific time period required between addition of the gel breaker and the breaking of the gel. As will be understood, the greater the quantity of gel breaker used, the shorter will be such time period.

The gelled aqueous carrier liquid containing the coated sand can be crosslinked to increase its viscosity if desired.

A variety of surface active agents can be utilized to promote substantially instantaneous coating of particulate material with the resin in the presence of a gelled aqueous carrier liquid, but the preferred surface active agent is a mixture of one or more cationic surface active agents and one or more non-cationic surface active agents. As used herein, a non-cationic surface active agent includes a blend of anionic and non-ionic surface active agents.

A surface active agent is the ingredient necessary to produce the substantially instantaneous coating of the particulate material with the epoxy resin in the presence of the gelled aqueous carrier liquid. A non-cationic surface active agent will achieve the desired coating when certain galactomannan gelling agents are utilized, but the preferred surface active agent is a blend of cationic and non-cationic surface active agents.

The cationic surface active agents useful herein are preferably the reaction product of an alcohol, epichlorohydrin and triethylenediamine wherein monohydric aliphatic alcohols having in the range of from about 12 to about 18 carbon atoms are reacted with from 2 to 3 moles of epichlorohydrin per mole of alcohol followed by reaction with an excess of triethylenediamine. The alcohol epichlorohydrin reaction product contains an ethoxylation chain having pendent chlorides. The subsequent reaction with triethylenediamine provides a cationic and a tertiary amine functionality to the resulting surfactant product.

The non-cationic surfactants are preferably ethoxylated fatty acids produced by reacting fatty acids containing from about 12 to about 22 carbon atoms with from about 5 to about 20 moles of ethylene oxide per mole of acid, most preferably from about 12 to about 18 moles of ethylene oxide per mole of acid, to produce a mixture of various quantities of ethoxylated acids and unreacted acids.

When the gelling agent used herein is a cellulose derivative, then one preferred surface active agent is a blend comprised of isopropyl alcohol, the cationic agent described above and the non-cationic agent described above wherein the weight ratio of cationic agent to non-cationic agent in the blend is in the range of about 0.4 to 1, and preferably about 0.6, parts by weight cationic agent per 1 part by weight non-cationic agent and wherein the weight ratio of isopropyl alcohol to non-cationic agent in the blend is about 1 part by weight alcohol per 1 part by weight non-cationic agent.

When the gelling agent used herein is a galactomannan gum, then one preferred surface active agent is a blend comprised of amyl alcohol, the cationic agent described above and the non-cationic agent described above wherein the weight ratio of cationic agent to non-cationic agent in the blend is in the range of about 0 to 1, and preferably about 0.2, parts by weight cationic agent per 1 part by weight non-cationic agent and wherein the weight ratio of amyl alcohol to non-cationic agent in the blend is about 1 part by weight alcohol per 1 part by weight non-cationic agent.

The alcohol constituent of the above described blends functions as a solubilizer and diluent for the cationic and non-cationic surfactants. Appropriate substitutes for amyl alcohol include other similar alcohols, for example isopropyl alcohol, n-hexanol and fusel oil.

A substantially continuous stream of the surface active agent utilized is mixed with the gelled aqueous carrier liquid, the resin composition and the particulate material at a rate whereby the amount of active surface active agent present in the mixture is in the range of from about 0.25 to about 10.0 gallons of surface active agent per 1000 gallons of gelled aqueous carrier liquid. Most preferably, when a galactomannan gelling agent is used, the active surface active agent is present in the mixture in an amount of about 0.5 gallon per 1000 gallons of gelled aqueous carrier liquid; when a cellulose derivative gelling agent is used, the active surface active agent is present in an amount of about 2 gallons per 1000 gallons of gelled aqueous carrier liquid.

Various types of particulate material can be used in accordance with the present invention, e.g., sand, sintered bauxite, etc. The preferred particulate material is sand, the particle size of which being in the range of from about 10 to about 70 mesh U.S. Sieve Series, with the preferred sizes being 10-20 mesh, 20-40 mesh or 40-60 mesh, or 50-70 mesh depending upon the particle size and distribution of formation sand adjacent to which the resin coated sand is to be deposited.

A substantially continuous stream of sand is combined with the gelled aqueous carrier liquid-surface active agent-resin composition mixture at a rate whereby the amount of sand present in the mixture is in the range of from about 2 to about 20 pounds of sand per gallon of gelled aqueous carrier liquid. Most preferably, the sand is present in the mixture in an amount in the range of from about 3 to about 15 pounds per gallon of carrier liquid.

The resin composition utilized in accordance with this invention for substantially instantaneously coating particulate material in the presence of the above-described surface active agent and gelled aqueous carrier liquid is comprised of a hardenable polyepoxide resin (epoxy resin), a solvent system, a hardener, a coupling agent, and a hardening rate controller. The polyepoxide resin, the hardener and the coupling components of the resin agent composition substantially instantaneously coat the particulate material in the presence of the gelled aqueous carrier liquid and the surface active agent.

The resin composition, above defined, is present in the mixture of ingredients in the range of from about 1.00 to about 20 pounds of resin composition per each 100 pounds of particulate material. It is believed that the density of the resin composition will vary in the range from about 1.05 to about 1.16 grams per milliliter depending upon the specific content of the composition.

While various polyepoxide resins can be utilized, preferred resins are the condensation products of epichlorohydrin and bisphenol A. A commercially available such product is marketed by the Shell Chemical Company of Houston, Tex., under the trade name EPON 828. EPON 828 resin exhibits good temperature stability and chemical resistance and has a viscosity of about 15,000 centipoises.

In one preferred embodiment, the solvent system is comprised of a first, polar, organic diluent which, in all cases, is miscible with the polyepoxide resin and substantially immiscible with water, and a second polar, organic, diluent which, in all cases, is miscible with but substantially non-reactive with the polyepoxide resin. The first and second diluents are present in the resin composition in amounts sufficient to adjust the viscosity of the resin composition to a level in the range of from about 100 centipoises to about 800 centipoises.

The first polar organic diluent is present in the resin composition in the range of from about 2 to about 35, preferably from about 15 to about 30, and most preferably about 28 parts by weight per 100 parts by weight of the epoxy resin component. The second polar organic diluent is present in the resin composition in the range of from about 4 to 20, preferably from about 8 to 15 and most preferably about 10 parts by weight per 100 parts by weight of the epoxy resin component.

In a more preferred system, the second polar organic diluent is also substantially immiscible with water.

In the most preferred system, the first polar organic diluent is also substantially reactive with the epoxy resin component.

The preferred first polar organic diluent which is reactive with the epoxy resin component is selected from the group consisting of butyl glycidyl ether, cresol glycidyl ether, allyl glycidyl ether, phenyl glycidyl ether or any other glycidyl ether which is miscible with the epoxy resin. Of these, butyl glycidyl ether and ortho-cresol glycidyl ether are the most preferred. The reactive diluent reacts with the hardening agent and also functions to reduce the viscosity of the epoxy resin.

The second polar organic diluent which is not reactive with the epoxy resin component is essential because it contributes to the lowering of the viscosity of the resin, and, in combination with the surface active agent, brings about the substantially instantaneous coating of the particulate material with the resin in the presence of the gelled aqueous carrier liquid.

The preferred non-reactive diluent is of low molecular weight, is miscible with the epoxy resin, is substantially immiscible with water and is selected from the group consisting of compounds having the structural formula: ##STR1## wherein: R is (Cn H2n+1) and n is an integer in the range of from about 1 to about 5;

R1 is (Cm H2m+1) and m is 0 or an integer in the range of from 1 to about 4, or ##STR2## and y is an integer in the range of from 1 to about 4, and X is independently H or OH; and

R2 is Ca H2a and a is an integer in the range of from 2 to about 5.

Of the various compounds falling within the group described above, ethyl acetate, butyl lactate, ethyl lactate, amyl acetate, ethylene glycol diacetate and propylene glycol diacetate are preferred. Of these, butyl lactate is the most preferred. Butyl lactate has a molecular weight of 130 and a water solubility of 1 gram per 1,000 grams of water.

Methyl alcohol, which is partially soluble in the polyepoxide resin, and other low molecular weight alkanols also are useful second diluents.

Other chemicals such as tetrahydrofurfuryl methacrylate and ethyl acetate can be either the first or the second polar organic diluent as each of these do satisfy the definitions of both types of diluents as set out above.

A variety of hardening agents can be used in this invention to cause the hardening of the resin. Examples of such hardening agents include amines, polyamines, amides and polyamides known to those skilled in the art. A preferred hardening agent is methylene dianiline, either dissolved in a suitable solvent such as ethyl acetate or in a liquid eutectic mixture of amines diluted with methyl alcohol. A particularly preferred hardening agent is a liquid eutectic mixture of amines diluted with about 22% by weight methyl alcohol, the eutectic mixture containing about 79% by weight methylene dianiline with the remaining amines being comprised of primary aromatic amines and meta-phenylene diamine. Such a liquid eutectic mixture is commercially available under the trade name TONOX 22 from the Uniroyal Chemical Co. of Naugatuck, Conn.

The quantity of hardening agent useful herein is dependent to a great extent upon the chemical nature of the hardener itself. It is, accordingly, difficult to specify in detail the amount of hardener to be used. However, in a broad sense, it is believed that the hardener is present in the range of from about 2 to about 150 parts by weight per 100 parts by weight of epoxy resin. When the hardener is an aromatic amine, the weight range is from about 8 to about 50. One aromatic amine, methylene dianiline, is useful when present in the range of from about 25 to about 38 parts by weight per 100 parts by weight of epoxy resin. When the hardener is an aliphatic amine, for example a dimethylaminomethyl substituted phenol, the hardener weight range is from about 2 to about 15 parts by weight per 100 parts by weight of epoxy resin.

The mixture of ingredients also preferably includes a resin-to-particulate material coupling agent to promote bonding of the resin to the particulate material such as a functional silane. Preferably, a N-beta-(aminoethyl)-gamma -aminopropyltrimethoxysilane resin-to-sand coupling agent is included in an amount in the range of from about 0.1 to about 2 parts by weight per 100 parts by weight of epoxy resin. A commercially available product is Union Carbide Silane A-1120 (Danbury, Conn.).

The mixture can also include retarders or accelerators as hardening rate controllers to lengthen or shorten the working and cure times of the resin. When retarders are used, low molecular weight organic acid ester retarders are preferred. Examples of such retarders are alkyl esters of low molecular weight alkyl acids containing about 2 to 3 carbon atoms. Suitable accelerators include 2,4,6-tris dimethyl amino methyl phenol, the ethyl hexonate salt thereof, and weak organic acids such as fumaric, erythorbic, ascorbic, salicylic and maleic acids. If a retarder or accelerator is utilized, it is combined therewith in an amount up to about 0 to 10 parts by weight per 100 parts by weight of epoxy resin.

As mentioned above, if it is desired to increase the viscosity of the gelled aqueous carrier liquid-resin composition coated particulate material slurry, a continuous stream of liquid crosslinker can be combined with the slurry depending upon the type of gelling agent utilized. Examples of crosslinkers which can be utilized are those selected from the group consisting of titanium, aluminum, zirconium and borate salts. Preferred crosslinkers are titanium lactate, titanium triethanolamine, aluminum acetate and zirconium salts. Generally, the crosslinker used is in the form of a solvent containing solution which is combined with the slurry at a rate which results in the crosslinker being present in an amount equivalent to the range of from about 0.05 to about 5.0 gallons of an approximately 30% by weight solution of the crosslinker per 1000 gallons of gelled aqueous carrier liquid. Also, depending upon the particular crosslinker used, a pH buffering agent may be combined with the gelled aqueous carrier liquid-coated particulate material slurry.

Based upon 100 parts by weight of epoxy resin, the resin composition is preferably comprised of the above-described epichlorohydrin-bisphenol A epoxy resin (100 parts by weight), a water immiscible reactive diluent comprised of ortho-cresol glycidyl ether present in an amount in the range of from about 20 parts by weight to about 35 parts by weight, a nonreactive diluent comprised of butyl lactate present in an amount in the range of from about 4 parts by weight to about 12 parts by weight and a hardening agent comprised of a water miscible solvent diluted liquid eutectic mixture of primary aromatic amines, methylene dianiline and metaphenylene diamine present in an amount in the range of from about 25 parts by weight to about 45 parts by weight. When the water immiscible reactive diluent used in the resin composition is butyl glycidyl ether instead of ortho-cresol glycidyl ether, it is present in an amount in the range of from about 2 parts by weight to about 20 parts by weight.

The above-described resin composition has a viscosity in the range of from about 400 centipoises to about 150 centipoises, and has an approximate working time without retarders or accelerators present, i.e., a time period between mixing and when the viscosity of the composition exceeds about 1500 centipoises, of about 2 hrs. at normal ambient conditions (about 72° F.). The cure time for the resin composition, i.e., the time from when the viscosity reaches about 1500 centipoises to when the resin composition has fully hardened is about 80 hrs. at 72° F.

A specific preferred resin composition for use in accordance with the present invention is comprised of 100 parts by weight of an epichlorohydrin and bisphenol A epoxy resin, butyl glycidyl ether present in an amount of about 11 parts by weight, butyl lactate present in an amount of about 8 parts by weight, a liquid eutectic mixture of primary aromatic amines, methylene dianiline and metaphenylene diamine diluted with about 22% by weight methyl alcohol present in an amount of about 36 parts by weight, N-beta (aminoethyl)-gamma-aminopropyltrimethoxysilane present in an amount of about 0.8. parts by weight, and the ethyl hexonate salt of dimethyl amino methyl phenol present in an amount of about 7 parts by weight. This resin composition has a viscosity of about 200 centipoises, a working time of about 0.5 hours and a cure time of about 8 hrs. at 80° F. When the accelerator (ethyl hexonate salt of dimethyl amino methyl phenol) is not present in the composition, it has a working time of about 2.0 hrs. and a cure time of about 84 hrs.

In carrying out the method of the present invention, and referring to FIG. 1, an aqueous gelled carrier liquid is first prepared in a container 10 by combining a polysaccharide polymer of the type described above with fresh water, brine or seawater. The water and polymer are carefully mixed with slow agitation whereby the polymer is hydrated. Alternatively, the gel may be made from a concentrated solution of gelling agent as is known to those skilled in the art.

A substantially continuous stream of the aqueous gelled carrier liquid from the container 10 is conducted by way of a conduit 12 to a mixing tub 14. Simultaneously, a continuous stream of liquid surface active agent of the type described above is preferably conducted from a container 16 to the conduit 12 by way of a conduit 18 connected therebetween.

A substantially continuous stream of particulate material, e.g., sand, is conducted to the mixing tub 14 from a container 20 by a conveyor 22 connected therebetween.

The liquid epoxy resin composition described above may be premixed in a container 24, and a substantially continuous stream thereof is continuously conducted therefrom to the mixing tub 14 by way of a conduit 26 connected therebetween.

Simultaneously with all of the above-described streams of components, a substantially continuous stream of liquid gel breaker is preferably conducted from a container 28 to the conduit 12 by a conduit 30. The liquid gel breaker combines with the gelled aqueous carrier liquid and the surface active agent flowing through the conduit 12 and is conducted therewith to the mixing tub 14.

As indicated in the drawing, the liquid gel breaker or a powdered solid gel breaker can optionally be introduced directly into the mixing tub 14. Occasionally the gel breaker is handled in a solid form, either as a powder or as an adsorbate on inert particles, such as sand, salt or sugar. These can be directly introduced into the mixing tub. If desired to provide this flexibility, the conduit 30 can contain a shut-off valve 32, and a conduit 34 having a shut-off valve 36 disposed therein can connect the conduit 30 upstream of the shut-off valve 32 to the mixing tub 14 whereby the liquid gel breaker can be introduced directly into the mixing tub. However, as will be understood by those skilled in the art, any container-conduit arrangement can be utilized which brings the component streams described into the mixing tub 14 or equivalent mixing apparatus simultaneously.

The component streams are intimately mixed in the mixing tub 14 and remain therein for a residence time of approximately 10 seconds. During such time, the particulate material is coated with the resin composition and suspended in the gelled aqueous carrier liquid.

The gelled aqueous carrier liquid-resin coated particulate material slurry formed in the mixing tub 14 is withdrawn therefrom by way of a conduit 38 which conducts a continuous stream of the slurry to one or more pumps 40. A conduit 42, connected to the discharge of the pumps 40, conducts the slurry to a conduit system disposed in a well bore and to a subterranean zone wherein the resin coated particulate material is to be deposited and consolidated into a hard permeable mass. If a crosslinker is utilized, it is added to the slurry downstream of the mixing tub 14, i.e., the crosslinker is conducted from a container 44 to the conduit 38 by a conduit 46 connected therebetween.

The resin coated particulate material can be utilized in the performance of gravel packing procedures or as a proppant material in fracturing treatments performed upon a subterranean formation. The resin coated particulate also can be utilized in the formation of controlled permeability synthetic formations within a zone of a subterranean formation.

A significant aspect of the methods of this invention is the ability to substantially instantaneously coat the particulate material with the resin composition and continuously suspend the coated particulate material in a continuous stream of gelled aqueous carrier liquid. This is accomplished by the particular resin composition and combination of component streams which promote the coating of the resin composition on the particulate material. The continuous stream of gelled aqueous carrier liquid-resin coated particulate material slurry formed is generally insensitive to variations in pH within the range of from about 5 to about 8.5 and variations in temperature within the range of from about 45° F. to about 100° F. The cure time of the resin composition can be short, i.e., less than about 6 hrs., and the resin composition can aquire substantial strength rapidly, i.e., within a time period of about 12 hours or less.

As is well understood by those skilled in the art, it may be desirable to condition the formation adjacent the consolidation placement location by preflushing the formation. Also, after-flushes may be used to insure uniform placement, consolidation and maximum permeability of the deposited particulate material as well as of particulate material existing in the formation.

In order to further illustrate the methods of the present invention and facilitate a clear understanding thereof, the following examples are given.

Tests are performed to determine the effectiveness of various resin compositions containing various reactive and non-reactive diluents to coat sand and to produce highstrength consolidations therefrom in the presence of water gelled with various gelling agents.

EXAMPLE 1

______________________________________Formulation:______________________________________Tap water               1     literPotassium chloride      20    gramsSodium diacetate        1.2   gramsHydroxypropyl guar1 (HPG)                   4.8   gramsFumaric acid            0.5   grams______________________________________ 1 Contains 0.39 moles propylene oxide substituents per pyranose unit
Procedure

The tap water, potassium chloride and sodium diacetate are mixed to produce a solution. The hydroxypropyl guar (HPG) is then added to the solution and stirred. Thereafter, the fumaric acid is added. The resulting mixture is then permitted to stand overnight in a covered container. The pH of the formed gel is in the range of about 6.8 to about 7.5.

Tests are conducted using samples of the HPG gel formed above, together with other ingredients.

______________________________________Formulation:HPG gel             250.00  mlSurfactant mixture1               0.25    mlResin composition2               21.00   ml (1.148 gm/ml)Ottawa Sand 40/60 mesh (USS)               450.00  grams1 Surfactant Mixture:Amyl alcohol        45      parts by weight                       of mixtureCationic surface active agent               10      parts by weight(previously described)      of mixtureNon cationic surface active agent               45      parts by weight(previously described)      of mixture2 Resin Composition:EPON 828 (Shell Chemical Com-               100     parts by weightpany) reaction product ofepichlorohydrin andBisphenol AHardener Blend      42      parts by weighteutectic mixture of primaryaromatic amines, meta-phenylene diamine, methylenedianiline (about 78% by weightof hardener blend)methyl alcohol (about 22% byweight of hardener blend)Silane Coupling Agent               0.66    parts by weightN--beta-(aminoethyl)-gamma-aminopropyltrimethoxysilaneDiluent 1                   Variable parts                       by weightDiluent 2                   Variable partsnon-reactive diluent (varies)                       by weight______________________________________
Procedure

The ingredients are mixed together to form slurries each of which is stirred for two minutes in a beaker and then transferred to a laboratory consistometer cup and stirred for an additional 60 minutes. Each slurry is examined visually and poured into one or more tubes to permit consolidation of the sand. The consolidation tubes are glass tubes coated with mold release agent and stoppered at one end. The sand in each slurry within each tube is tamped down and allowed to cure for 20 hours at the temperature indicated in Table I. After curing, the glass tubes are broken and the consolidated sand samples are tested for compressive strength. The results of these tests are given in Table I below.

                                  TABLE I__________________________________________________________________________COMPRESSIVE STRENGTH OF SAND CONSOLIDATIONS                            CureDiluent 1          Diluent 2     Tempera-                                  CompressiveRun          Parts         Parts ture, Strength,No.   Chemical  By Weight1              Chemical                      By Weight1                            °F.                                  psi__________________________________________________________________________1  butyl glycidyl ether        27    butyl lactate                      7     170   55002  butyl glycidyl ether        14    methyl alcohol                      7     170   53403  butyl glycidyl ether        13    methyl alcohol                      7     120   36004  butyl glycidyl ether        14    ethyl acetate                      14    170   35605  butyl glycidyl ether        30    THFMA2                      7     170   21006  THFMA2        11    methyl alcohol                      6     170   20007  ethyl acetate        14.5  methyl alcohol                      5     120   16008  ethyl acetate        10    methyl alcohol                      5     120   15609  ethyl acetate        25    methyl alcohol                      6     170   147010 --              ethyl acetate                      28    120    400__________________________________________________________________________ 1 Based on 100 parts by weight of epoxy resin 2 tetrahydrofurfuryl methacrylate

From Table I it can be seen that the consolidations having the highest compressive strength contain both a reactive and a non-reactive diluent in the resin composition and that when the resin composition contains a butyl glycidyl ether reactive diluent and butyl lactate non-reactive diluent, an excellent consolidation is achieved.

EXAMPLE 2

Tests are conducted to determine the sand coating times of various resin compositions in the presence of water gelled with hydroxypropylguar and a surfactant.

250 cc samples of aqueous gel containing surfactant and 40-60 mesh Ottawa sand are prepared in accordance with the procedure and in the quantities described in Example 1. The resin compositions described in Table II below are prepared and added to the gel surfactant sand samples in amounts of 28 ml of resin composition per sample. After adding the resin composition, each mixture is stirred in a beaker and the time for coating to take place determined by visual observation. That is, the resin composition is deemed to coat when resin does not remain in the gel when stirring is stopped. Excess resin is easily visible if coating has not occurred as it settles in a layer on top of the sand with the gelled water above the resin.

In tests 3, 4 and 5, using the same resin composition, the stirring is stopped after 5, 10 and 60 second intervals and the samples immediately transferred to consolidation tubes, cured at 170° F. and tested for compressive strength. The results of these tests are given in Table II below.

              TABLE II______________________________________COATING TIMES OF VARIOUS RESIN COMPOSITIONS            Amount            in ResinResin       Composition,Test Formulation Parts by   Mixing  CompressiveNo.  Components  Weight     Time    Strength______________________________________1    epoxy1,3            55         about 5 sec.                               Not run -butyl lactate            4                  samplecresyl glycidyl            15                 coatedethermethyl alcohol            6hardener2            202    epoxy1,3            55         1 to 5 sec.                               Not run -butyl lactate            4                  samplecresyl glycidyl            15                 coatedethermethyl alcohol            6hardener2            203    epoxy resin1,3            55         5 sec   2206 psibutyl lactate            4cresyl glycidyl            15ethermethyl alcohol            6hardener2            204    epoxy resin1,3            55         10 sec  2950 psibutyl lactate            4cresyl glycidyl            15ethermethyl alcohol            6hardener2            205    epoxy resin1,3            55         60 sec  3100 psibutyl lactate            4cresyl glycidyl            15ethermethyl alcohol            6hardener2            20______________________________________ 1 Shell Chemical Co., EPON 828 2 Liquid eutectic mixture of primary aromatic amines, methylene dianiline (79% by weight) and metaphenylene diamine. 3 All tests had 0.5 parts by weight N--beta(aminoethyl)-gamma-aminopropyltrimethoxysilane
EXAMPLE 3

A test is run to determine the compressive strength of a sand consolidation formed in accordance with the present invention at a temperature of 250° F. A gelled aqueous carrier liquid is prepared by adding 9.6 grams of hydroxyethylcellulose (D.S. of 2.5) to one liter of fresh water having 30 grams of potassium chloride dissolved therein. After hydration of the hydroxyethylcellulose, 4 ml of a surfactant blend comprised of 50 parts by weight amyl alcohol, 37 parts by weight non cationic surfactants and 13 parts by weight cationic surfactants is combined with the aqueous gel followed by 1800 grams of 40-60 mesh (U.S. Sieve Series) Ottawa sand and 84 ml of the resin composition described in Table III below.

The resulting slurry is stirred in a beaker for 2 minutes and then transferred to a laboratory consistometer cup and stirred for an additional 60 minutes. After stirring, the slurry is poured into a consolidation tube and allowed to cure in the same manner as described in Example 1 for 48 hours at 170° F. The temperature is then gradually raised to 250° F. and the sample is allowed to cure for an additional 48 hours. After curing, the consolidation is cooled over a 4-hour period to room temperature, trimmed, and prepared for compressive strength testing. The sample is then gradually reheated to 250° F., at which temperature compression strength testing is carried out. The results of this test are given in Table III below.

              TABLE III______________________________________COMPRESSIVE STRENGTH OF SAND CONSOLIDATIONResin Composition        Amount, Parts                    Compressive StrengthComponents   by Weight   at 250° F.______________________________________epoxy1  60.0        2510 psibutyl lactate        5.0butyl glycidyl ether        6.0Hardener2        21.0coupling agent3        0.5methyl alcohol        7.0______________________________________ 1 Shell Chemical Co. EPON 828 2 Liquid eutectic mixture of primary aromatic amines, methylene dianiline (about 79% by weight) and metaphenylene diamine 3 N--beta(aminoethyl)-gamma-aminopropyltrimethoxysilane
EXAMPLE 4

Tests are conducted to determine the effect of order of addition of components on the compressive strengths of the consolidations formed.

A gelled aqueous liquid is formed utilizing hydroxy-ethylcellulose in accordance with the procedure set forth in Example 1. To 250-milliliter samples of the aqueous gel, surfactant described in Example 1, sand described in Example 1, the resin composition of Table III and an accelerator comprised of 2,4,6-tris dimethyl amino methyl phenol are added to the aqueous gel in various orders of introduction. The resulting slurries are each stirred for one minute in a beaker and then transferred to a laboratory consistometer cup and stirred for an additional 60 minutes. Each slurry is then poured into a consolidation tube and allowed to cure for the time and at the temperature indicated in Table IV below. The compressive strength of the resulting consolidations are determined.

The results of these tests are given in Table IV below.

              TABLE IV______________________________________EFFECT OF ORDER OF ADDITION ON COMPRESSIVESTRENGTH OF CONSOLIDATIONS                       Com-            Cure       pressiveOrder of Addition to Gel              Time,   Tempera- Strength,1       2        3         hr    ture, °F.                                   psi______________________________________Surfactant   Sand     Resin     20     80    2840            (including            DMP-301)Surfactant   Sand     Resin     20    100    3160            (including            DMP-30)Surfactant   Sand     Resin     20    140    3940            (including            DMP-30)Surfactant   Sand     Resin     48    140    5660            (including            DMP-30)Surfactant   Sand     Resin     20     80    1220andDMP-30Surfactant   Resin (in-            Sand      24    120    5360   cluding   DMP-30)______________________________________ 1 DMP30 is 2,4,6tris dimethylamino methyl phenol, an accelerator.
EXAMPLE 5

The laboratory system illustrated schematically in FIG. 2 is used to simulate the equipment used in acutal field operations and for carrying out the methods of this invention. The system is comprised of a gelled aqueous carrier liquid container 50 connected by tubing 52 to the suction connection of a 1/3 horsepower, 3,425 rpm centrifugal feed pump 54. A shut-off valve 56 is disposed in the tubing 52.

A liquid surfactant blend container 58 is connected to the suction connection of a concentric cam fluid metering pump 60 by tubing 62 having a shut-off valve 64 therein. The discharge connection of the pump 60 is connected to the tubing 52 by tubing 66. The discharge connection of a 50 cc syringe pump 68 for injecting liquid gel breaker is connected by tubing 70 to the tubing 52.

The discharge connection of the feed pump 54 is connected by tubing 72 to a 450 cc over-flow mixing tub 74 equipped with an electric stirrer 76.

A liquid resin composition container 78 is connected to the inlet connection of a concentric cam fluid metering pump 80 by tubing 82 having a shut-off valve 84 disposed therein. The discharge of the pump 80 is connected by tubing 86 to the tubing 72.

A sand container 88 is positioned above the mixing tub 74 having a sand outlet 90. A shut-off valve 92 is disposed in the outlet 90 which is positioned to introduce sand into the mixing tub 74.

When a test run is made, the valves 56, 64, and 84 are opened and the pumps 54, 60, 68 and 80 are started whereby continuous streams of gelled aqueous carrier liquid, resin composition, surfactant blend and gel breaker, at desired flow rates, are pumped into the mixing tub 74. Simultaneously, a continuous stream of sand is introduced into the mixing tub 74 by way of valve 92 and outlet 90 at a desired flow rate. The stirrer 76 is activated whereby a gelled aqueous carrier liquid-resin coated sand slurry is formed in the mixing tub 74.

The slurry produced in the mixing tub 74 overflows the tub conducted by way of tubing 94 connected thereto and to an air-powered opposed piston discharge pump 96. The discharge connection of the pump 96 is connected by tubing 98 to a container 100 for receiving the slurry.

A liquid crosslinker container 102 is connected by tubing 104 to the inlet connection of a high pressure pump 108. A shut-off valve 106 is disposed in the tubing 104 and a tubing 110 connects the discharge conneciton of the pump 108 to the tubing 94. When a crosslinker is combined with the slurry flowing through the pump 96 into the receiver 100, it is injected into the slurry by way of the pump 108, tubing 110 and tubing 94 at a controlled continuous flow rate.

The various component streams and flow rates thereof utilized in carrying out the tests using the laboratory apparatus described above are as follows:

Gelled aqueous carrier liquid is introduced into the container 50. The gelled aqueous carrier liquid is comprised of a 2% KCl brine gelled with hydroxypropylguar in an amount of 40 pounds per 1,000 gallons of brine. The gelled aqueous carrier liquid is conducted from the container 50 to the feed pump 54 at a flow rate of 1/2 gallon per minute to 1 gallon per minute whereby continuous flow can be sustained for about 20 minutes before refilling of the container 50 is necessary.

The liquid resin composition used is described in Example 3. The resin composition is introduced into the container 78, and the flow rate of resin composition pumped the pump 80 is varied up to 56 cc per minute. Sand from the container 88 is introduced into the mixing tub 74 at a varied rate of 1 pound to 4 pounds per minute whereby a resin-to-sand ratio of about 0 to 0.6 gallons of resin composition per 100 pounds of sand results in the mixing tub 74.

The liquid surfactant blend described in Example 1 is introduced into the container 58 and pumped to the feed pump 54 at a rate in the range of from 0.0 cc per minute to 8.4 cc per minute.

The liquid gel breaker utilized is an enzyme breaker of a type previously described herein and is used as a 1 gram per 100 cc aqueous solution. The solution is introduced to the feed pump 54 at the rate of 10 cc per minute.

The crosslinker utilized is prepared by diluting a solution of titanium triethanolamine with 50% by volume tap water at least 30 minutes and not more than 2 hours before use. When used, the crosslinker is pumped into the slurry flowing through the tubing 94 at a rate equivalent to about 0 to about 0.8 cc of crosslinker per liter of slurry.

Gelled aqueous carrier liquid-resin coated particulate slurries are formed in the mixing tub 54 and colmaterial lected in the slurry receiver 100. Portions of the slurries are poured into consolidation tubes and compressive strength tests are conducted as described in Example 1. The results of these tests with and without cross-linker are given in Table V below.

                                  TABLE V__________________________________________________________________________Amount of Amount of              Amount of Gel                       Amount of Cross-                                AmountResin Composition     Surfactant Used,              Breaker Used,1                       linker Used,                                of Sand Used, lb.                                         Cure Compres-Used, cc per Liter     cc per Liter of              cc per Liter of                       cc per Liter of                                per Gallon of                                         Temper-                                              siveof Gelled Aqueous     Gelled Aqueous              Gelled Aqueous                       Gelled Aqueous                                Gelled Aqueous                                         ature,                                              StrengthCarrier Liquid     Carrier Liquid              Carrier Liquid                       Carrier Liquid                                Carrier Liquid                                         °F.                                              psi__________________________________________________________________________10        1        1        .4       4        170   5010        4        1        0        4        170  15011        4        1        .4       2        170  158__________________________________________________________________________ 1 Gel breaker diluted 1 g/100 cc tap water.
EXAMPLE 6

The procedure of Example 5 is repeated except that the amount of surfactant used, the amount of crosslinker used and the cure temperature are varied. The results of these tests are given in Table VI below.

                                  TABLE VI__________________________________________________________________________COMPRESSIVE STRENGTHS USING VARYING AMOUNTSOF SURFACTANT AND CROSSLINKERAmount of Amount of              Amount of Gel                       Amount of Cross-                                AmountResin Composition     Surfactant Used,              Breaker Used,1                       linker Used,                                of Sand Used, lb.                                         Cure Compres-Used, cc per Liter     cc per Liter of              cc per Liter of                       cc per Liter of                                per Gallon of                                         Temper-                                              siveof Gelled Aqueous     Gelled Aqueous              Gelled Aqueous                       Gelled Aqueous                                Gelled Aqueous                                         ature,                                              StrengthCarrier Liquid     Carrier Liquid              Carrier Liquid                       Carrier Liquid                                Carrier Liquid                                         °F.                                              psi__________________________________________________________________________15        2.7      1        0        4         72  15015        4.5      1        0        4         72  50015        4.5      1        0.8      4        170  67015        2.5      1        0.8      4        170  785 0        1.5      1        0.8      4        170   0__________________________________________________________________________ 1 Gel breaker diluted, 1 g/100 cc tap water
EXAMPLE 7

The procedure of Example 6 is repeated except that the surfactant utilized is comprised of an aqueous 50 parts by weight amyl alcohol solution having the cationic surface active agents described previously herein dissolved therein in an amount of abaout 7 parts by weight, and the non-cationic surface active agents described previously dissovled therein in an amount of about 43 parts by weight; the crosslinker is titanium triethanolamine; and the sand concentration is varied. The results of these tests are given in Table VII below.

                                  TABLE VII__________________________________________________________________________COMPRESSIVE STRENGTHS USING VARYING AMOUNTSOF SURFACTANT AND CROSSLINKERAmount of Amount of              Amount of Gel                       Amount of Cross-                                AmountResin Composition     Surfactant Used,              Breaker Used,1                       linker Used,                                of Sand Used, lb.                                         Cure Compres-Used, cc per Liter     cc per Liter of              cc per Liter of                       cc per Liter of                                per Gallon of                                         Temper-                                              siveof Gelled Aqueous     Gelled Aqueous              Gelled Aqueous                       Gelled Aqueous                                Gelled Aqueous                                         ature,                                              StrengthCarrier Liquid     Carrier Liquid              Carrier Liquid                       Carrier Liquid                                Carrier Liquid                                         °F.                                              psi__________________________________________________________________________28        2        1        0        4        170  391015        2        1        0.8      4        170   93415        3        1        0.8      2        170   55015        3        1        0        4        170  1070__________________________________________________________________________ 1 Gel breaker diluted, 1 g/100 cc tap water.
EXAMPLE 8

The procedure of Example 6 is repeated except that the gelled aqueous carrier liquid is formed using 50 pounds of hydroxyethylcellulose per 1,000 gallons of brine, the gel breaker is an aqueous enzyme breaker solution (1 gram cellulase per 100 cc) and the surfactant is an aqueous 50 parts by weight isopropyl alcohol solution having the cationic surface active agents described previously herein dissolved therein in an amount of about 20 parts by weight, and the non-cationic surface active agents described previously dissolved therein in an amount of about 30 parts by weight. The results of these tests are given in Table VIII below.

                                  TABLE VIII__________________________________________________________________________COMPRESSIVE STRENGTHS USING VARYING AMOUNTS OF SURFACTANTAmount of Resin Composition          Amount Surfactant                     Amount of Gel Breaker                                  Amount of Sand Used,Used, cc per Liter          Used, cc per Liter of                     Used, cc per Liter of                                 lb. per Gallon of                                            Cure   Compressiveof Gelled Aqueous          Gelled Aqueous                     Gelled Aqueous                                 Gelled Aqueous                                            Temperature,                                                   StrengthCarrier Liquid Carrier Liquid                     Carrier Liquid                                 Carrier Liquid                                            °F.                                                   psi__________________________________________________________________________16             2          1           4          160    255016             3          1           4          160    268016             4          1           4          160    4290__________________________________________________________________________

While that which is considered to be the preferred embodiments of the invention has been described hereinbefore, it is to be understood that modifications and changes can be made in the methods and compositions without departing from the spirit or scope of the invention as hereinafter set forth in the claims.

Citas de patentes
Patente citada Fecha de presentación Fecha de publicación Solicitante Título
US3625287 *3 Feb 19707 Dic 1971Halliburton CoMethod of improving strength and stability of sand consolidations made with resin systems
US4074760 *1 Nov 197621 Feb 1978The Dow Chemical CompanyMethod for forming a consolidated gravel pack
US4101474 *16 Jun 197718 Jul 1978The Dow Chemical CompanyAqueous based epoxy slurry for forming a consolidated gravel pack
US4199484 *6 Oct 197722 Abr 1980Halliburton CompanyGelled water epoxy sand consolidation system
US4247430 *11 Abr 197927 Ene 1981The Dow Chemical CompanyAqueous based slurry and method of forming a consolidated gravel pack
Citada por
Patente citante Fecha de presentación Fecha de publicación Solicitante Título
US4964465 *6 Nov 198923 Oct 1990Texaco Inc.Method employing liquidized sand for controlling lost circulation of drilling fluids
US5058676 *30 Oct 198922 Oct 1991Halliburton CompanyMethod for setting well casing using a resin coated particulate
US5095987 *31 Ene 199117 Mar 1992Halliburton CompanyMethod of forming and using high density particulate slurries for well completion
US5128390 *22 Ene 19917 Jul 1992Halliburton CompanyTertiary amine or zwitterion
US5211234 *30 Ene 199218 May 1993Halliburton CompanyHorizontal well completion methods
US5226479 *9 Ene 199213 Jul 1993The Western Company Of North AmericaFracturing subterranean formations
US5232961 *19 Ago 19913 Ago 1993Murphey Joseph RAdducts of a diamine and the diglycidyl ether of Bisphenol A as hardeners for polyepoxides; prevention of migration of sand from subterranean formation into oil well bores; nontoxic
US5321062 *20 Oct 199214 Jun 1994Halliburton CompanyEnhances ability of hardenable polyepoxide resin to coat and bond to material
US5368102 *9 Sep 199329 Nov 1994Halliburton CompanyConsolidatable particulate material and well treatment method
US5393810 *30 Dic 199328 Feb 1995Halliburton CompanyMethod and composition for breaking crosslinked gels
US5420174 *2 Nov 199230 May 1995Halliburton CompanyMethod of producing coated proppants compatible with oxidizing gel breakers
US5775425 *19 May 19977 Jul 1998Halliburton Energy Services, Inc.Control of fine particulate flowback in subterranean wells
US5791415 *13 Mar 199711 Ago 1998Halliburton Energy Services, Inc.Injecting hardenable resin into portion of formation, creating fracture, depoisting hardenable resin coated proppant in fracture and hardening; prevents migration of formation sand with fluids
US5799734 *18 Jul 19961 Sep 1998Halliburton Energy Services, Inc.Method of forming and using particulate slurries for well completion
US5804612 *1 May 19968 Sep 1998Arkwright, IncorporatedHydroxyl group containing polymer, aluminum containing crosslinker, surface active agent; for windows, lenses
US5833000 *18 Feb 199710 Nov 1998Halliburton Energy Services, Inc.Control of particulate flowback in subterranean wells
US5839510 *14 Ene 199724 Nov 1998Halliburton Energy Services, Inc.Control of particulate flowback in subterranean wells
US5853048 *21 Abr 199829 Dic 1998Halliburton Energy Services, Inc.Control of fine particulate flowback in subterranean wells
US5871049 *21 May 199816 Feb 1999Halliburton Energy Services, Inc.Control of fine particulate flowback in subterranean wells
US5921317 *14 Ago 199713 Jul 1999Halliburton Energy Services, Inc.Coating well proppant with hardenable resin-fiber composites
US5934376 *26 May 199810 Ago 1999Halliburton Energy Services, Inc.Methods and apparatus for completing wells in unconsolidated subterranean zones
US5944105 *11 Nov 199731 Ago 1999Halliburton Energy Services, Inc.Of a subterranean zone or formation penetrated by a wellbore
US5960880 *27 Ago 19965 Oct 1999Halliburton Energy Services, Inc.Unconsolidated formation stimulation with sand filtration
US6003600 *16 Oct 199721 Dic 1999Halliburton Energy Services, Inc.Methods of completing wells in unconsolidated subterranean zones
US6012524 *14 Abr 199811 Ene 2000Halliburton Energy Services, Inc.Remedial well bore sealing methods and compositions
US6047772 *9 Nov 199811 Abr 2000Halliburton Energy Services, Inc.Control of particulate flowback in subterranean wells
US6059035 *20 Jul 19989 May 2000Halliburton Energy Services, Inc.Subterranean zone sealing methods and compositions
US6069117 *20 Ago 199930 May 2000Halliburton Energy Services, Inc.Foamed resin compositions for sealing subterranean zones
US6079492 *7 Oct 199827 Jun 2000Halliburton Energy Services, Inc.Methods of rapidly consolidating particulate materials in wells
US6098711 *18 Ago 19988 Ago 2000Halliburton Energy Services, Inc.Compositions and methods for sealing pipe in well bores
US6124246 *17 Nov 199726 Sep 2000Halliburton Energy Services, Inc.High temperature epoxy resin compositions, additives and methods
US6155348 *25 May 19995 Dic 2000Halliburton Energy Services, Inc.Stimulating unconsolidated producing zones in wells
US6209643 *6 Mar 20003 Abr 2001Halliburton Energy Services, Inc.Method of controlling particulate flowback in subterranean wells and introducing treatment chemicals
US62316648 Mar 200015 May 2001Halliburton Energy Services, Inc.Slag cement
US623425122 Feb 199922 May 2001Halliburton Energy Services, Inc.Resilient well cement compositions and methods
US62443449 Feb 199912 Jun 2001Halliburton Energy Services, Inc.Comprised of hydraulic cement, epoxy resin, and water to form a pumpable slurry
US62711814 Feb 19997 Ago 2001Halliburton Energy Services, Inc.Sealing subterranean zones
US627965223 Sep 199828 Ago 2001Halliburton Energy Services, Inc.Heat insulation compositions and methods
US631177328 Ene 20006 Nov 2001Halliburton Energy Services, Inc.Resin composition and methods of consolidating particulate solids in wells with or without closure pressure
US632184121 Feb 200127 Nov 2001Halliburton Energy Services, Inc.Methods of sealing pipe strings in disposal wells
US63281062 Nov 200011 Dic 2001Halliburton Energy Services, Inc.Sealing subterranean zones
US633091723 Ene 200118 Dic 2001Halliburton Energy Services, Inc.Resilient well cement compositions and methods
US635030913 Feb 200126 Feb 2002Halliburton Energy Services, Inc.A hydraulic cement, an epoxy resin, a hardening agent, and water, introducing into the annulus between the pipe string and well bore, and allowing to set into a resilient impermeable solid mass
US640181730 Ago 200111 Jun 2002Halliburton Energy Services, Inc.Sealing subterranean zones
US642777521 Sep 19996 Ago 2002Halliburton Energy Services, Inc.Methods and apparatus for completing wells in unconsolidated subterranean zones
US644820630 Ago 200110 Sep 2002Halliburton Energy Services, Inc.Sealing subterranean zones
US64814947 Mar 200019 Nov 2002Halliburton Energy Services, Inc.Method and apparatus for frac/gravel packs
US654002219 Feb 20021 Abr 2003Halliburton Energy Services, Inc.Method and apparatus for frac/gravel packs
US65555077 May 200129 Abr 2003Halliburton Energy Services, Inc.Sealing subterranean zones
US655763526 Jun 20026 May 2003Halliburton Energy Services, Inc.Methods for completing wells in unconsolidated subterranean zones
US657187213 Nov 20013 Jun 2003Halliburton Energy Services, Inc.Apparatus for completing wells in unconsolidated subterranean zones
US65934026 Feb 200115 Jul 2003Halliburton Energy Services, Inc.Sealing pipe to well bore; butadiene-styrene latex
US66689268 Ene 200230 Dic 2003Halliburton Energy Services, Inc.Methods of consolidating proppant in subterranean fractures
US669851918 Ene 20022 Mar 2004Halliburton Energy Services, Inc.Methods of forming permeable sand screens in well bores
US670540028 Ago 200216 Mar 2004Halliburton Energy Services, Inc.Methods and compositions for forming subterranean fractures containing resilient proppant packs
US672593130 Sep 200227 Abr 2004Halliburton Energy Services, Inc.Methods of consolidating proppant and controlling fines in wells
US672940426 Jun 20024 May 2004Halliburton Energy Services, Inc.Methods and compositions for consolidating proppant in subterranean fractures
US675524518 Dic 200229 Jun 2004Halliburton Energy Services, Inc.Apparatus for completing wells in unconsolidated subterranean zones
US6766858 *4 Dic 200227 Jul 2004Halliburton Energy Services, Inc.Method for managing the production of a well
US677623616 Oct 200217 Ago 2004Halliburton Energy Services, Inc.Methods of completing wells in unconsolidated formations
US679301724 Jul 200221 Sep 2004Halliburton Energy Services, Inc.Method and apparatus for transferring material in a wellbore
US686609912 Feb 200315 Mar 2005Halliburton Energy Services, Inc.Methods of completing wells in unconsolidated subterranean zones
US69622004 Abr 20038 Nov 2005Halliburton Energy Services, Inc.Methods and compositions for consolidating proppant in subterranean fractures
US697883623 May 200327 Dic 2005Halliburton Energy Services, Inc.Methods for controlling water and particulate production
US701397625 Jun 200321 Mar 2006Halliburton Energy Services, Inc.Compositions and methods for consolidating unconsolidated subterranean formations
US701766526 Ago 200328 Mar 2006Halliburton Energy Services, Inc.Strengthening near well bore subterranean formations
US70213797 Jul 20034 Abr 2006Halliburton Energy Services, Inc.Methods and compositions for enhancing consolidation strength of proppant in subterranean fractures
US702877416 Ago 200518 Abr 2006Halliburton Energy Services, Inc.Applying a preflush solution of an aqueous liquid and a water-resistant polymer, surfactant, low viscosity consolidating fluid and afterflush fluid to the subterranean formation
US703266710 Sep 200325 Abr 2006Halliburtonn Energy Services, Inc.Methods for enhancing the consolidation strength of resin coated particulates
US705940626 Ago 200313 Jun 2006Halliburton Energy Services, Inc.Production-enhancing completion methods
US706315025 Nov 200320 Jun 2006Halliburton Energy Services, Inc.Methods for preparing slurries of coated particulates
US70631515 Mar 200420 Jun 2006Halliburton Energy Services, Inc.Methods of preparing and using coated particulates
US70662588 Jul 200327 Jun 2006Halliburton Energy Services, Inc.Reduced-density proppants and methods of using reduced-density proppants to enhance their transport in well bores and fractures
US707358115 Jun 200411 Jul 2006Halliburton Energy Services, Inc.Electroconductive proppant compositions and related methods
US7090017 *9 Jul 200315 Ago 2006Halliburton Energy Services, Inc.pumping a mixture of fracture fluid and sand suspension into a centrifugal pump to adjust the concentration, then injecting the mixture downhole into the subterranean formation using a separate pump
US71145608 Jun 20043 Oct 2006Halliburton Energy Services, Inc.Methods for enhancing treatment fluid placement in a subterranean formation
US71145707 Abr 20033 Oct 2006Halliburton Energy Services, Inc.Reducing production and preventing migration of loose particulates; applying aqueous liquid and surfactant preflush solution, integrated consolidation fluid and afterflush fluid; noncatalytic
US713149316 Ene 20047 Nov 2006Halliburton Energy Services, Inc.Methods of using sealants in multilateral junctions
US715619426 Ago 20032 Ene 2007Halliburton Energy Services, Inc.Methods of drilling and consolidating subterranean formation particulate
US721052818 Mar 20041 May 2007Bj Services CompanyMethod of treatment subterranean formations using multiple proppant stages or mixed proppants
US72115473 Mar 20041 May 2007Halliburton Energy Services, Inc.Controlling the migration of particulates by curing and degrading a mixture of a resin, a hardening agent, a hydrocarbon diluent, a silane coupling agent, a foaming agent, a compressible gas, and a hydrolytically degradable material to form a permeable, hardened resin mass.
US721365110 Jun 20048 May 2007Bj Services CompanyIntroducing a first fluid to create a segment extending through the subterranean formation; and introducing a second fluid with a different viscosity and density to create a finger or channel within the fluid segment; at least one of the fluids contains a proppant; minimized proppant flowback
US721671115 Jun 200415 May 2007Halliburton Eenrgy Services, Inc.Methods of coating resin and blending resin-coated proppant
US723760929 Oct 20043 Jul 2007Halliburton Energy Services, Inc.Methods for producing fluids from acidized and consolidated portions of subterranean formations
US72521464 Abr 20067 Ago 2007Halliburton Energy Services, Inc.Methods for preparing slurries of coated particulates
US72551692 Feb 200514 Ago 2007Halliburton Energy Services, Inc.Methods of creating high porosity propped fractures
US72611564 Mar 200528 Ago 2007Halliburton Energy Services, Inc.Slurrying particulates including an adhesive coated with a subterranean treatment partitioning agent in a treatment fluid placing the slurry into a portion of a subterranean formation
US72640514 Mar 20054 Sep 2007Halliburton Energy Services, Inc.Providing partitioned, coated particulates that comprise particulates, an adhesive, and a partitioning agent, and wherein adhesive comprises an aqueous tackifying agent or a silyl modified polyamide; slurrying particulates in a treatment fluid, placing slurry into subterranean formation
US726405223 May 20054 Sep 2007Halliburton Energy Services, Inc.Methods and compositions for consolidating proppant in fractures
US726717125 Oct 200411 Sep 2007Halliburton Energy Services, Inc.Methods and compositions for stabilizing the surface of a subterranean formation
US72730993 Dic 200425 Sep 2007Halliburton Energy Services, Inc.Methods of stimulating a subterranean formation comprising multiple production intervals
US72815809 Sep 200416 Oct 2007Halliburton Energy Services, Inc.Fracturing a portion of a subterranean formation to form a propped fracture; slurrying fracturing fluid and high density plastic particles coated with adhesive
US72815811 Dic 200416 Oct 2007Halliburton Energy Services, Inc.Methods of hydraulic fracturing and of propping fractures in subterranean formations
US72998758 Jun 200427 Nov 2007Halliburton Energy Services, Inc.Methods for controlling particulate migration
US730603720 Sep 200411 Dic 2007Halliburton Energy Services, Inc.Reducing number and prevent migration of particles; preflushing with aqueous solution containing surfactant; noncatalytic reaction
US73184737 Mar 200515 Ene 2008Halliburton Energy Services, Inc.Methods relating to maintaining the structural integrity of deviated well bores
US731847411 Jul 200515 Ene 2008Halliburton Energy Services, Inc.Methods and compositions for controlling formation fines and reducing proppant flow-back
US733463514 Ene 200526 Feb 2008Halliburton Energy Services, Inc.Methods for fracturing subterranean wells
US73346368 Feb 200526 Feb 2008Halliburton Energy Services, Inc.Methods of creating high-porosity propped fractures using reticulated foam
US734397311 Feb 200518 Mar 2008Halliburton Energy Services, Inc.Methods of stabilizing surfaces of subterranean formations
US734501114 Oct 200318 Mar 2008Halliburton Energy Services, Inc.Via injecting consolidating furan-based resin
US73505717 Mar 20061 Abr 2008Halliburton Energy Services, Inc.Methods of preparing and using coated particulates
US740701016 Mar 20065 Ago 2008Halliburton Energy Services, Inc.Methods of coating particulates
US741301015 Feb 200619 Ago 2008Halliburton Energy Services, Inc.Remediation of subterranean formations using vibrational waves and consolidating agents
US741301724 Sep 200419 Ago 2008Halliburton Energy Services, Inc.Methods and compositions for inducing tip screenouts in frac-packing operations
US743108820 Ene 20067 Oct 2008Halliburton Energy Services, Inc.Methods of controlled acidization in a wellbore
US745511229 Sep 200625 Nov 2008Halliburton Energy Services, Inc.Well bores; acid-generaters; esters, formates, lactic acids, methyl lactate, ethyl lactate, propyl lactate, butyl lactate; gelling agent is natural biopolymers, synthetic polymers, viscoelastic surfactants; diverting agent is degradable dextran particulate, oil-soluble resins, water-soluble rock salt
US746169721 Nov 20059 Dic 2008Halliburton Energy Services, Inc.Placing the treatment fluid containing coated particulates having been treated with a surface modification agent and coated with a hydrolysable coating into a subterranean formation via a well bore
US747572823 Jul 200413 Ene 2009Halliburton Energy Services, Inc.Treating subterranean formation with treatment fluid containing a base fluid, a viscosifier, a fluid loss control additive, and a degradable bridging agent such as, polysaccharide, a chitin, a chitosan, a protein, a polyester, a poly(glycolide), a poly( lactide), polycarbonate etc., allowing to degrade
US748456416 Ago 20053 Feb 2009Halliburton Energy Services, Inc.Delayed-acid releasing activator comprises an orthoacetate, orthoformate, orthopropionate or a polyorthoester; stabilization of subterranean formations; tackifier resins comprising polymethyl (meth)acrylate, poly(meth)acrylic acid, acrylamido-2-methylpropanesulfonic acid polymers and the like; fracturing
US749725822 Jul 20053 Mar 2009Halliburton Energy Services, Inc.Methods of isolating zones in subterranean formations using self-degrading cement compositions
US750668922 Feb 200524 Mar 2009Halliburton Energy Services, Inc.Fracturing fluids comprising degradable diverting agents and methods of use in subterranean formations
US754766529 Abr 200516 Jun 2009Halliburton Energy Services, Inc.Acidic treatment fluids comprising scleroglucan and/or diutan and associated methods
US755380017 Nov 200430 Jun 2009Halliburton Energy Services, Inc.In-situ filter cake degradation compositions and methods of use in subterranean formations
US759528016 Ago 200529 Sep 2009Halliburton Energy Services, Inc.Delayed tackifying compositions and associated methods involving controlling particulate migration
US759820816 May 20066 Oct 2009Halliburton Energy Services, Inc.Filter cake degradation compositions and methods of use in subterranean operations
US760856630 Mar 200627 Oct 2009Halliburton Energy Services, Inc.Degradable particulates as friction reducers for the flow of solid particulates and associated methods of use
US760856712 May 200527 Oct 2009Halliburton Energy Services, Inc.Degradable surfactants and methods for use
US762133429 Abr 200524 Nov 2009Halliburton Energy Services, Inc.Acidic treatment fluids comprising scleroglucan and/or diutan and associated methods
US763731922 Jul 200529 Dic 2009Halliburton Energy Services, Inc,Biodegradable; acid-based cements
US764098522 Jul 20055 Ene 2010Halliburton Energy Services, Inc.Placing where desired in the well bore a self-degrading cement composition and a source of acid, base or water; setting, hardening, and degrading to allow fluidcommunication where the plug is partially restored; removing plug with a drill string and continue drilling enhanced oil recovery
US764894617 Nov 200419 Ene 2010Halliburton Energy Services, Inc.Methods of degrading filter cakes in subterranean formations
US766275312 May 200516 Feb 2010Halliburton Energy Services, Inc.Treating subterranean formations such as well bores with aqueous fluids of biodegradable polymeric surfactants with are block polymers e.g. polyethylene glycol-polylactic acid copolymer; environmental regulations
US766551715 Feb 200623 Feb 2010Halliburton Energy Services, Inc.Methods of cleaning sand control screens and gravel packs
US76747535 Dic 20069 Mar 2010Halliburton Energy Services, Inc.drilling a well bore in a subterranean formation, using a treatment fluid containing a base fluid, a viscosifier, a fluid loss control additive, and a degradable bridging agent such as, an aliphatic polyester
US76860809 Nov 200630 Mar 2010Halliburton Energy Services, Inc.Acid-generating fluid loss control additives and associated methods
US770052523 Sep 200920 Abr 2010Halliburton Energy Services, Inc.Orthoester-based surfactants and associated methods
US771391622 Sep 200511 May 2010Halliburton Energy Services, Inc.synthesized from a diketene acetal or multiketene acetal by addition of hydrophobic alcohol such as fatty alcohol, a fatty alcohol ethoxylate, an end-capped hydrophobic poly(alkylene oxide), poly(tetrahydrofuran), polybutadiene hydroxyl terminated; and a hydrophilc alochol e.g. endcapped polyoxyglycol
US774006730 Abr 200722 Jun 2010Halliburton Energy Services, Inc.Method to control the physical interface between two or more fluids
US777679723 Ene 200617 Ago 2010Halliburton Energy Services, Inc.a crosslinkable copolymer of butyl acrylate/tert-/ and acryamide, polyethylenimine as crosslinking agent; filler is alkyl quaternary ammonium montmorillonite; for introducing the formulation into a wellbore and penetrating a subterranean formation to reduce the loss of fluid to the formation
US782950717 Sep 20039 Nov 2010Halliburton Energy Services Inc.drilling a well bore in a subterranean formation, using a treatment fluid containing a base fluid, a viscosifier, a fluid loss control additive, and a degradable bridging agent such as, polysaccharide, a chitin, a chitosan, a protein, a polyester, a poly(glycolide), a poly( lactide), polycarbonate etc.
US783394326 Sep 200816 Nov 2010Halliburton Energy Services Inc.mixing zwitterionic surfactant( laurylamindopropyl betaines or sultaine or alkylamine oxide) a co-surfactant( alkyl alcohol e.g butanol), and water to form a microemulsifier, contacting the microemulsifier with an oleaginous fluid under low shear conditions to form a microemulsion for well bore servicing
US783394418 Jun 200916 Nov 2010Halliburton Energy Services, Inc.drilling a well bore in a subterranean formation, using a treatment fluid containing a base fluid, a viscosifier, a fluid loss control additive, and a degradable bridging agent such as, an aliphatic polyester ( crosslinked polylactic acid); reduced fluid loss
US790646413 May 200815 Mar 2011Halliburton Energy Services, Inc.Compositions and methods for the removal of oil-based filtercakes
US791827731 Dic 20085 Abr 2011Baker Hughes IncorporatedMethod of treating subterranean formations using mixed density proppants or sequential proppant stages
US79381818 Feb 201010 May 2011Halliburton Energy Services, Inc.Method and composition for enhancing coverage and displacement of treatment fluids into subterranean formations
US796031430 Sep 201014 Jun 2011Halliburton Energy Services Inc.Microemulsifiers and methods of making and using same
US800676010 Abr 200830 Ago 2011Halliburton Energy Services, Inc.Clean fluid systems for partial monolayer fracturing
US808299213 Jul 200927 Dic 2011Halliburton Energy Services, Inc.Methods of fluid-controlled geometry stimulation
US813262323 Ene 200613 Mar 2012Halliburton Energy Services Inc.Methods of using lost circulation compositions
US818801311 Mar 200929 May 2012Halliburton Energy Services, Inc.Self-degrading fibers and associated methods of use and manufacture
US82056759 Oct 200826 Jun 2012Baker Hughes IncorporatedMethod of enhancing fracture conductivity
US822054812 Ene 200717 Jul 2012Halliburton Energy Services Inc.Surfactant wash treatment fluids and associated methods
US83296216 Abr 200711 Dic 2012Halliburton Energy Services, Inc.Degradable particulates and associated methods
US8541051 *15 Dic 200324 Sep 2013Halliburton Energy Services, Inc.On-the fly coating of acid-releasing degradable material onto a particulate
US85980928 Nov 20073 Dic 2013Halliburton Energy Services, Inc.Methods of preparing degradable materials and methods of use in subterranean formations
US20140144638 *28 Nov 201229 May 2014Halliburton Energy Services, Inc.Methods for Controlling Unconsolidated Particulates in a Subterranean Formation
EP0497055A1 *20 Dic 19915 Ago 1992Halliburton CompanyHigh density particulate slurries for well completion
EP0864726A212 Mar 199816 Sep 1998Halliburton Energy Services, Inc.Stimulating wells in unconsolidated formations
EP0909874A214 Oct 199821 Abr 1999Halliburton Energy Services, Inc.Completing wells in unconsolidated subterranean zones
WO2011061504A218 Nov 201026 May 2011Haliburton Energy Services IncCompositions and systems for combatting lost circulation and methods of using the same
Clasificaciones
Clasificación de EE.UU.523/131, 523/426, 523/417, 166/295, 523/402
Clasificación internacionalC08L63/00, C08J3/215, C09K8/80, C09K8/56, C09K8/575
Clasificación cooperativaC08J2363/00, C08J3/215, C09K8/805, C08L63/00, C09K8/5751
Clasificación europeaC09K8/575B, C09K8/80B, C08J3/215, C08L63/00
Eventos legales
FechaCódigoEventoDescripción
2 Nov 2000FPAYFee payment
Year of fee payment: 12
4 Nov 1996FPAYFee payment
Year of fee payment: 8
19 Oct 1992FPAYFee payment
Year of fee payment: 4
23 Sep 1988ASAssignment
Owner name: HALLIBURTON COMPANY, DUNCAN, OK A CORP. OF DE
Free format text: ASSIGNMENT OF ASSIGNORS INTEREST.;ASSIGNORS:MURPHEY, JOSEPH R.;TOTTY, KENNETH D.;REEL/FRAME:004948/0077
Effective date: 19880920
Owner name: HALLIBURTON COMPANY, A CORP. OF DE,OKLAHOMA
Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:MURPHEY, JOSEPH R.;TOTTY, KENNETH D.;REEL/FRAME:4948/77
Owner name: HALLIBURTON COMPANY, A CORP. OF DE, OKLAHOMA
Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:MURPHEY, JOSEPH R.;TOTTY, KENNETH D.;REEL/FRAME:004948/0077